Hind.Oil Explor. Q1 FY27 Earnings Call — Analysis (NSE: HINDOILEXP)

HOEC reports Q1 FY27 consolidated net revenue of ₹114 Cr, plans B-80 workovers by end-2026 and Dirok gas grid connectivity by Dec-26 to drive production ramp.

20 Aug 2026 · Analysis by Alpha Inflection

Result quality: stable — Steady quarter. Management sentiment: neutral.

The take

Q1FY27 Consolidated net revenue ₹114.17 Cr ( +recovery from negative ₹194 Cr standalone revenue in Q4FY26 QoQ ) . New guidance — Q1FY28 total production rate 11,000 boepd (8,900-13,000 range) . New story: Production recovery through intervention .

Results

Consolidated net revenue ₹114.17 Cr after recovering from HPCL reversal; standalone PBT before exceptionals ₹12.54 Cr; Kharsang production up 41% QoQ to 17,400 BOE; crude realizations improved to $95.5/bbl and gas to $12/MMBTU.

Financial highlights

Guidance

Dirok gas evacuation via DNPL pipeline expected by Dec-26; B-80 workovers Nov-Dec 2026 and 3 new wells by Jun-27 targeting ~11,000 boepd; debt raise for B-80 drilling.

What management committed to

• Rig for B-80 workover of wells D1 and D2 to be awarded in August 2026, rig mobilized by October 2026, and workovers completed by November-December 2026. — Q3FY27
• Three new development wells at [B-80] to be drilled and brought on production by June 2027. — Q1FY28
• [HOEC] aims to achieve total production of 11,000 barrels of oil equivalent per day (range 8,900-13,000 boepd) by June 2027, following B-80 workovers and new wells. — 11,000 boepd (8,900-13,000 range), Q1FY28
• DNPL pipeline hot tapping to be completed and [Dirok] gas evacuation to national grid to commence by December 2026. — Q3FY27
• [HOEC] is in the process of raising debt to fund the [B-80] program of three wells and two workovers.
• [HOEC] will not drill the two new wells at PY-1 until a firm take-or-pay gas sales agreement is signed with GAIL or IOCL.
• 24 km gas pipeline from [Kharsang] to [Oil India grid at Bordumsa] to be completed in 14-18 months, enabling gas monetization. — Q4FY28

Key themes

Production ramp-up and evacuation de-bottlenecking

How the narrative shifted

• Production recovery through intervention: Management is prioritizing workovers and infill drilling at B-80 and PY-1 to reverse declines, emphasizing reservoir potential despite historical delays.
• Evacuation infrastructure de-bottlenecking: Dirok gas bottleneck being addressed via hot tap and common carrier status; Kharsang pipeline route survey initiated; both critical for monetization.
• Capital discipline and external funding: With low gearing, the company plans to raise debt to fund the B-80 campaign, while self-funding smaller interventions.
• Oil price & inventory realization risk: Crude inventory from HPCL dispute is being sold at a loss due to lower Brent, impacting quarter's profitability; conciliation process ongoing.
• Regulatory and policy support: Common carrier declaration and Samudra Manthan scheme seen as tailwinds for gas monetization and sector support.
• Operational risks and reservoir uncertainty: Water cut, subsea well interventions, and drilling outcomes are inherently uncertain; management stresses technical preparedness but acknowledges volatility.
• India energy security long-term demand: Management frames growth within the context of India's 7-8% GDP growth and energy security push, underpinning long-term value.

Operational commentary

• B-80 subsea workover of wells D1 and D2: rig award targeted in Aug-26, mobilization Oct-26, workovers Nov-Dec 2026; compressor reconfiguration to series mode completed to sustain output despite higher water cut.
• Dirok gas evacuation: DNPL pipeline declared common carrier; hot tapping to restore full 2.5 MMSCMD capacity underway, targeted completion by Dec-26, enabling gas flow to national grid without NRL shutdown.
• Kharsang: production doubled YoY; second phase of 9-well drilling imminent with rig identified and tubulars ordered; 24 km gas pipeline route survey tender closing, pipeline to Oil India grid at Bordumsa targeted in 14-18 months.
• PY-1: rig-less intervention awarded to boost short-term production from existing wells; two new development wells contingent on securing firm take-or-pay gas sales agreement with GAIL/IOCL.
• B-15: FDP under preparation, evaluating concepts including tie-back to ONGC platform to reduce Capex; drilling targeted in FY28; 2P reserves 16 MMBOE with potential upside.
• Cambay assets: belt technology trial at Balol, debottlenecking at Palej with thermionic heaters; 5-6% QoQ production increase already seen, further 20-30% increase expected; sucker rod pumps ordered; new exploration block near Palej in final approval stage.
• HPCL crude inventory: sold 15% of stored volumes to third parties; balance expected by Oct-Nov 2026; estimated loss of 7-10% on Brent decline; conciliation process with HPCL under High Court-appointed Chief Justice.
• Debt raise initiated to fund B-80 three-well and two-workover program; internal accruals to fund other interventions.

Analyst Q&A

• Q. What would have been the EBITDA adjusted for inventory losses and other adjustments?

  CFO: 'Let me come back to you on that because I don't want to give you this -- it's a bit of a technical issue.'

• Q. Why not pass on the Brent price loss on HPCL crude to HPCL, given it's their fault?

  We have agreed on a way forward and a collaborative atmosphere; a conciliation process is on. We want to preserve the relationship as long-term partners.

• Q. When will cash flows become sufficient for capex commitments?

  For B-80 we will rely on debt; by Q4 Nov-Dec 2027, cash flows should be sufficient to fund B-15 growth.

• Q. Will you provide asset-wise gas realizations going forward?

  CFO: 'Point well taken. We will in our next presentation make sure that we include the offshore and onshore realizations as well.'

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